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Noble Energy Announces Second Quarter 2015 Results

Press Release

Company raises full year volumes while maintaining total capital and cost outlook

HOUSTON, Aug. 3, 2015 (GLOBE NEWSWIRE) -- Noble Energy, Inc. (NYSE:NBL) announced today a second quarter 2015 net loss of $109 million, or $0.28 per diluted share. Excluding the impact of certain items which would typically not be considered by analysts in published earnings estimates, second quarter 2015 adjusted income(1) was $101 million, or $0.26 per diluted share. Discretionary cash flow(1) was $461 million and net cash provided by operating activities was $424 million. Capital expenditures for the second quarter of 2015 totaled $799 million.

Mr. Stover continued, "Mid-year 2015 marks a strategic inflection point for Noble Energy. We have added new positions in some of the best areas of the Eagle Ford and Delaware Basins, and the integration of these assets is on track. At the same time, important infrastructure expansions in the DJ Basin provide the new capacity needed to support optimal production. We have also worked with the government of Israel on establishing a regulatory framework for natural gas development, which is progressing toward final approval."

"Looking forward, our production is ramping through the remainder of the year, while capital continues to trend lower each quarter. Production increases are driven from our onshore assets and major project startups in the Gulf of Mexico. In addition, we have two material offshore exploration wells currently drilling, one in the Falkland Islands and one in Cameroon, which provide substantial new resource potential. Our operational performance and financial strength will continue to deliver differential results for Noble Energy."

Total sales volumes for the quarter averaged 299 thousand barrels of oil equivalent per day (MBoe/d), an increase of three percent compared to the second quarter of 2014, or seven percent after adjusting for non-core assets divested during 2014. Liquids comprised 43 percent (33 percent crude oil and condensate and 10 percent natural gas liquids) of second quarter 2015 sales volumes, with natural gas the remaining 57 percent.

Higher sales volumes versus the 2014 period were primarily a result of continued development of the DJ Basin and Marcellus Shale plays, where combined production was up 28 percent. Horizontal production in these plays increased 45 percent compared to the second quarter of last year. Offshore sales volumes were lower than the 2014 period and were impacted by planned downtime and maintenance in the Gulf of Mexico and Equatorial Guinea. Assets sold in 2014, including production from the Piceance Basin and China, accounted for a 10 MBoe/d decrease from the second quarter of 2014 to 2015.

Second quarter 2015 total production costs, including lease operating expense, production and ad valorem taxes, and transportation and gathering declined to $7.83 per barrel of oil equivalent (Boe), a reduction of 17 percent versus the second quarter of 2014 and 13 percent versus the first quarter of 2015. Lease operating expense (LOE) was reduced to $4.74 per Boe in the second quarter of 2015, a decline of 19 percent from the second quarter of last year and 14 percent from the first quarter of this year. The lower LOE rate is a result of systematic cost reduction and efficiency initiatives as well as supplier pricing negotiations. General and administrative costs were $104 million, down nearly 20 percent from the same quarter of last year.

Adjustments to the net loss for the second quarter of 2015 included non-cash commodity derivative losses of $274 million, as a result of the value change of the Company's existing crude oil and natural gas hedge positions as of the end of the quarter. The Company also adjusted from earnings certain asset impairments ($15 million), corporate restructuring costs ($18 million), and the termination of the Company's defined benefit pension program ($21 million). The effective tax rate on adjusted income was an overall tax benefit of nearly 150 percent, reflecting current tax expense related to foreign income in Equatorial Guinea and Israel and a deferred tax benefit in the Company's U.S. operations.

ROSETTA RESOURCES INC. ACQUISITION

On July 20, 2015, the stockholders of Rosetta overwhelmingly approved the acquisition by Noble Energy. Highlights of the acquisition include:

Approximately 50,000 net acres in the Eagle Ford Shale and 54,000 net acres in the Permian (45,000 in the Delaware Basin and 9,000 in the Midland Basin).

More than 1,800 gross horizontal drilling locations identified for development, with net unrisked resource potential of approximately one billion barrels of oil equivalent.

Per well estimated ultimate recoveries have been increased 25 percent for Lower Eagle Ford wells in the South Gates Ranch area of the Eagle Ford Shale and 30 percent for Wolfcamp A wells in the Delaware Basin. Recent well results are outperforming even the enhanced type curves.

Noble Energy anticipates more than 15 percent compounded annual production growth from these assets to an average of more than 100 MBoe/d in 2018.

In the DJ Basin, sales volumes averaged 108 MBoe/d in the second quarter of 2015, up 10 percent versus the second quarter of last year. Liquids made up 66 percent of DJ Basin volumes (49 percent crude oil and condensate and 17 percent natural gas liquids) and 34 percent was natural gas. Second quarter 2015 sales volumes were impacted by heavy rainfall and isolated flooding throughout the DJ Basin, as well as high line pressures in the northern part of Wattenberg, which together reduced second quarter 2015 volumes by approximately three thousand barrels of oil equivalent per day.

Third-party gas processing capacity in Greater Wattenberg expanded late in the second quarter of 2015 with the Lucerne-2 gas processing plant, which is designed for 200 million cubic feet of natural gas per day (MMcf/d), commencing operation. Lucerne-2 is ramping toward full capacity, expanding total gas processing on the third-party system to more than 800 MMcf/d. Compression projects in Wattenberg, including the Rocky (100 MMcf/d) and Troudt (45 MMcf/d) compressor stations, also started-up by the end of the June 2015. Following the gas processing and compression additions, line pressures in the northern part of Greater Wattenberg have experienced a reduction of 50 to 75 psi during the early part of the third quarter. Construction has begun on the low-pressure line-loop system (DCP Grand Parkway) in the northern part of Wattenberg and is estimated for completion by the end of 2015 / early 2016.

Highlights for the quarter included:

Horizontal sales volumes totaled 90 MBoe/d, up more than 30 percent from the same quarter of last year.

Operated 4 drilling rigs in the Basin.

Drilled 44 wells at an average lateral length of more than 5,950 feet. The average spud to rig release time for a standard lateral length well (4,500 lateral feet) decreased to 6.1 days, or 24 percent lower than the corresponding time in the second quarter of 2014. The Company recently drilled a 9,287 foot lateral well in less than seven days.

Standard lateral length well costs, including allocated production facility costs, continue to decline and are anticipated to average $3.5 million in Wells Ranch and $3.9 million in East Pony for the second half of the year.

Long lateral well costs, normalized to a standard length lateral, are below $3.0 million. Approximately 60 percent of wells to be drilled in the second half of this year will be extended reach lateral wells.

Commenced production on 46 wells, including 11 extended reach lateral wells (equivalent to 57 standard length wells). 70 percent of wells that commenced production in the second quarter were located in the East Pony IDP, where production was up more than 100 percent from the second quarter of 2014, exiting the quarter at approximately 25 MBoe/d net.

The 100% owned Keota gas processing plant in the East Pony IDP area commenced operation.

The Tallgrass crude oil lateral pipeline connecting East Pony IDP production to the Pony Express pipeline to Cushing, started-up in the second quarter of 2015. Noble Energy is exporting approximately 85 percent of gross oil produced out of the basin via pipeline or rail.

MARCELLUS SHALE

Production volumes in the Marcellus Shale averaged a record 427 million cubic feet of natural gas equivalent per day (MMcfe/d), a 70 percent increase versus the same quarter of last year. Natural gas represented 86 percent of second quarter 2015 volumes, with the remaining 14 percent being condensate and natural gas liquids (NGLs).

In response to the current environment, the JV partnership is aligned to continue reducing drilling activity in the basin during the second half of the year. Operated horizontal drilling, with one rig currently active, will be reduced to zero rigs in the middle part of the third quarter. The Company's JV partner is currently running two horizontal rigs which will also be reduced to zero early in the fourth quarter.

Highlights for the quarter included:

Averaged 2 operated and 2 non-operated horizontal drilling rigs.

Drilled 20 operated wells at an average lateral length of 9,200 feet. Included in the wells drilled was a record 13,917 foot lateral on the OXF-97 pad in Doddridge County, West Virginia.

Reduced drilling cost per lateral foot to an average of approximately $300, more than 30 percent lower than the 2014 average. The OXF-97 pad, including 8 wells, is the Company's first operated pad to have all wells drilled to the curve point with a top hole rig.

Commenced production on 19 operated wells, having an average lateral length of 7,800 feet.

In the Gulf of Mexico, sales volumes averaged 12 MBoe/d, which were comprised of 75 percent crude oil and condensate, eight percent NGLs, and 17 percent natural gas. Planned third-party facility maintenance at the Na Kika platform and well operations at Galapagos reduced net production by approximately two thousand barrels of oil equivalent per day during the quarter.

Highlights for the quarter included:

Progress towards first production for the Big Bend and Dantzler fields remains on schedule. Pipeline installation for the Big Bend project is nearing completion. Big Bend (1 well), with total project completion of 85 percent, is planned to commence production in the fourth quarter of 2015. Dantzler (2 wells), which has a total project completion of 70 percent, is planned to startup around the end of the year. The two fields will tie back to the Thunderhawk production facility.

Successfully drilled a development well at Gunflint, encountering net pay and reservoir quality consistent with pre-drill expectations. Sidetrack drilling operations have commenced on the second development well at Gunflint. First production from the field is projected in mid-2016 as a two-well tieback to the Gulfstar 1 facility.

WEST AFRICA

Hydrocarbon sales in Equatorial Guinea averaged 68 MBoe/d, comprised of 46 percent crude oil and condensate, five percent NGLs, and 49 percent natural gas. Sales volumes for the quarter were reduced by planned facility maintenance at the Alba field and the associated LPG plant, representing a seven thousand barrels of oil equivalent per day impact to total sales volumes.

Highlights for the quarter included:

Active production management, facility optimization, and strong reservoir performance resulted in better than forecasted gross daily production averages of 33 MBbl/d for Aseng and 31 MBbl/d for Alen. Production volumes for Alen were a quarterly record.

Successfully drilled the C-21 development well at Alba. First production from the well is planned by the end of the third quarter of 2015.

Installation of compression upgrades at Alba is now 70 percent complete and expected to commence operation in 2016.

Drilling the Cheetah prospect, located in the shallow water offshore Cameroon, commenced in early July 2015. Results are anticipated by the end of the third quarter. Cheetah, with unrisked gross mean resources of more than 100 million barrels of oil equivalent, is a four-way structure and represents the Company's first Cretaceous oil prospect in Cameroon. Noble Energy operates the Cheetah prospect with a 47 percent interest.

EASTERN MEDITERRANEAN

In the Eastern Mediterranean, Israel natural gas sales volumes averaged 217 MMcfe/d, equivalent to the second quarter of last year, reflecting mild seasonal weather demand in the second quarter of 2015.

Highlights for the quarter included:

Submitted Declaration of Commerciality and Preliminary Development Plan for the Cyprus Aphrodite natural gas field. Noble Energy and partners are beginning regional gas marketing of the Aphrodite resource and performing pre-FEED work for a potential development connecting the Aphrodite field to natural gas customers in Egypt.

Worked with the government of Israel on establishing a regulatory framework to provide certainty necessary for future investment, which the government of Israel is progressing toward final approval.

OTHER

Drilling at the Humpback prospect, offshore the Falkland Islands, is underway. Humpback (NBL operated with a 35 percent interest), with more than 250 million barrels of gross unrisked oil resources, is anticipated to be at total depth by the end of the third quarter.

Commenced decommissioning of the MacCulloch field in the North Sea. Shut in of the field, which took place as expected, reduced Company volumes by approximately 800 Boe/d beginning May 2015.

Exited the second quarter of 2015 with $5.3 billion in financial liquidity, including $1.3 billion in cash and $4 billion of an unused credit facility.

OPERATIONAL AND FINANCIAL GUIDANCE

Total organic capital spend in 2015 remains unchanged at $2.9 billion for legacy Noble Energy assets plus $165 million incremental capex allocated to the Eagle Ford/Delaware assets (post the closing of the transaction).

Full year 2015 Noble Energy sales volumes, prior to the inclusion of Rosetta assets, have been increased to between 305 and 320 MBoe/d, reflecting strong confidence in underlying performance and development execution for the second half of the year. Third quarter sales volumes are anticipated to be 345 to 365 MBoe/d, which includes the Eagle Ford and Delaware assets for the period of July 20, 2015 to September 30, 2015. Fourth quarter 2015 sales volumes are expected to increase to a range of 375 to 400 MBoe/d.

Detailed volume and other guidance for the remainder of 2015 is as follows:

3Q 2015

4Q 2015

Crude Oil and Condensate (MBbl/d)

United States

80 - 83

92 - 96

Equatorial Guinea

23 - 25

33 - 36

Equatorial Guinea - equity method investment

1 - 2

1 - 2

Natural Gas (MMcf/d)

United States

710 - 730

780 - 800

Equatorial Guinea

200 - 220

200 - 220

Israel

260 - 285

230 - 255

Natural Gas Liquids (MBbl/d)

United States

41 - 44

45 - 49

Equatorial Guinea - equity method investment

4 - 6

4 - 6

Costs and Expenses

Lease operating ($/Boe)

$4.40 - $4.60

$4.25 - $4.50

Transportation and gathering ($/Boe)

$2.40 - $2.60

$2.40 - $2.60

Depreciation, depletion and amortization ($/Boe)

$15.50 - $16.00

$15.50 - $16.00

Production and ad valorem taxes (% of oil, gas, and NGL revenues)

3.8% - 4.2%

3.8% - 4.2%

Exploration ($MM)

$150 - $200

$60 - $100

General and administrative ($MM)

$120 - $135

$120 - $135

Interest ($MM net)

$80 - $90

$80 - $90

Other Items

Outstanding shares - diluted (MM)

420 - 430

430 - 440

Commodity Hedges

Noble Energy holds the following crude oil and natural gas derivative instruments for the remainder of 2015:

Crude Oil Hedges

Swaps

Collars

Average

Average

Average

Average

Volume

Price

Short Put Price

Floor Price

Ceiling Price

Type of Contract

Index

(Bbl/d)

($/Bbl)

($/Bbl)

($/Bbl)

($/Bbl)

Fixed Swaps

NYMEX WTI

27,000

$88.80

Fixed Swaps

Dated Brent

8,000

$100.31

Two-Way Collars

NYMEX WTI

5,000

$50.00

$64.94

Three-Way Collars

NYMEX WTI

20,000

$70.50

$87.55

$94.41

Three-Way Collars

Dated Brent

13,000

$76.92

$96.00

$108.49

Natural Gas Hedges

Swaps

Collars

Average

Average

Average

Average

Volume

Price

Short Put Price

Floor Price

Ceiling Price

Type of Contract

Index

(MMBtu/d)

($/MMBtu)

($/MMBtu)

($/MMBtu)

($/MMBtu)

Fixed Swaps

NYMEX HH

140,000

$4.30

Three-Way Collars

NYMEX HH

150,000

$3.58

$4.25

$5.04

Noble Energy hedges held by NBL Texas, LLC as of July 20, 2015 and for the remainder of 2015 are as follows:

Crude Oil Hedges

Swaps

Collars

Average

Average

Average

Average

Volume

Price

Short Put Price

Floor Price

Ceiling Price

Type of Contract

Index (2)

(Bbl/d)

($/Bbl)

($/Bbl)

($/Bbl)

($/Bbl)

Two-Way Collars

8,000

$55.00

$84.80

Fixed Swaps

12,000

$89.81

Natural Gas Hedges

Swaps

Collars

Average

Average

Average

Average

Volume

Price

Short Put Price

Floor Price

Ceiling Price

Type of Contract

Index (2)

(MMBtu/d)

($/MMBtu)

($/MMBtu)

($/MMBtu)

($/MMBtu)

Fixed Swaps

50,000

$4.13

Two-Way Collars

50,000

$3.60

$5.04

Natural Gas Liquids Hedges

Swaps

Collars

Average

Average

Average

Average

Volume

Price

Short Put Price

Floor Price

Ceiling Price

Type of Contract

Index

(Bbl/d)

($/Bbl)

($/Bbl)

($/Bbl)

($/Bbl)

Fixed Swaps

Ethane

2,476

$11.31

Fixed Swaps

Propane

1,750

$43.35

Fixed Swaps

Isobutane

617

$53.05

Fixed Swaps

Butane

579

$52.53

Fixed Swaps

Pentanes

579

$77.72

(1) A Non-GAAP measure, see attached Reconciliation Schedules

(2) Include a combination of NYMEX WTI and Argus LLS indices for crude oil hedges, and a combination of Houston Ship Channel and Tennessee Zone 0 indices for natural gas.

WEBCAST AND CONFERENCE CALL INFORMATION

Noble Energy, Inc. will host a webcast and conference call at 9:00 a.m. Central time today. The webcast is accessible on the 'Investors' page at www.nobleenergyinc.com. Conference call numbers for participation are 888-296-4197 and 719-457-2084. The pass code number is 5150352. A replay will be available on the website.

Noble Energy (NYSE:NBL) is a global independent oil and natural gas exploration and production company, with total proved reserves of 1.7 billion barrels of oil equivalent at year-end 2014 (pro forma for the Rosetta acquisition). The company's diverse resource base includes positions in four premier unconventional U.S. onshore plays - the DJ Basin, Marcellus Shale, Eagle Ford Shale and Permian Basin - and offshore in the U.S. Gulf of Mexico, Eastern Mediterranean and West Africa. Driven by its purpose, Energizing the World, Bettering People's Lives®, the company is committed to safely and responsibly providing energy to the world while positively impacting the lives of our stakeholders. For more information, visit www.nobleenergyinc.com.

This news release contains certain "forward-looking statements" within the meaning of federal securities law. Words such as "anticipates", "believes," "expects", "intends", "will", "should", "may", and similar expressions may be used to identify forward-looking statements. Forward-looking statements are not statements of historical fact and reflect Noble Energy's current views about future events. They include estimates of oil and natural gas reserves, estimates of future production, assumptions regarding future oil and natural gas pricing, planned drilling activity, future results of operations, projected cash flow and liquidity, business strategy and other plans and objectives for future operations. No assurances can be given that the forward-looking statements contained in this news release will occur as projected and actual results may differ materially from those projected. Forward-looking statements are based on current expectations, estimates and assumptions that involve a number of risks and uncertainties that could cause actual results to differ materially from those projected. These risks include, without limitation, the volatility in commodity prices for crude oil and natural gas, the presence or recoverability of estimated reserves, the ability to replace reserves, environmental risks, drilling and operating risks, exploration and development risks, competition, government regulation or other actions, the ability of management to execute its plans to meet its goals and other risks inherent in Noble Energy's business that are discussed in its most recent annual report on Form 10-K and in other reports on file with the Securities and Exchange Commission . These reports are also available from Noble Energy's offices or website, http://www.nobleenergyinc.com. Forward-looking statements are based on the estimates and opinions of management at the time the statements are made. Noble Energy does not assume any obligation to update forward-looking statements should circumstances, management's estimates, or opinions change.

The Securities and Exchange Commission requires oil and gas companies, in their filings with the SEC, to disclose proved reserves that a company has demonstrated by actual production or conclusive formation tests to be economically and legally producible under existing economic and operating conditions. The SEC permits the optional disclosure of probable and possible reserves, however, we have not disclosed the Company's probable and possible reserves in our filings with the SEC. We use certain terms in this news release, such as "net unrisked resource potential," "unrisked oil resources," "unrisked gross mean resources," and "type curves" which are by their nature more speculative than estimates of proved, probable and possible reserves and accordingly are subject to substantially greater risk of being actually realized. The SEC guidelines strictly prohibit us from including these estimates in filings with the SEC. Investors are urged to consider closely the disclosures and risk factors in our most recent annual report on Form 10-K and in other reports on file with the SEC, available from Noble Energy's offices or website, http://www.nobleenergyinc.com.

This news release also contains certain historical non-GAAP measures of financial performance that management believes are good tools for internal use and the investment community in evaluating Noble Energy's overall financial performance. These non-GAAP measures are broadly used to value and compare companies in the crude oil and natural gas industry. Please see the attached schedules for reconciliations of the differences between any historical non-GAAP measures used in this news release and the most directly comparable GAAP financial measures.

NOTE: Adjusted income should not be considered an alternative to, or more meaningful than, net income (loss) as reported in accordance with GAAP. Adjusted income is provided for comparison to earnings forecasts prepared by analysts and other third parties. Our management believes, and certain investors may find, that adjusted income is beneficial in evaluating our financial performance. We believe such measures can facilitate comparisons of operating performance between periods and with our peers. However, Noble Energy's method of computing this measure may not be the same method used to compute similar measures reported by other entities. See Schedule 2: Summary Statement of Operations.

[1] Many factors impact our gain or loss on commodity derivative instruments, net of cash settlements, including: increases and decreases in the commodity forward price curves compared to our executed hedging arrangements; increases in hedged future volumes; and the mix of hedge arrangements between NYMEX WTI, Dated Brent and NYMEX HH commodities. These gains or losses on commodity derivative instruments, net of cash settlements, recognized in the current period, will be realized in the future when cash settlement occurs.

[2] Amount for 2015 relates primarily to Eastern Mediterranean and Gulf of Mexico properties and amount for 2014 relates primarily to North Sea properties.

These financial statements should be read in conjunction with the financial statements and the accompanying notes and other information included in Noble Energy's Quarterly Report on Form 10-Q to be filed with the Securities and Exchange Commission on August 3, 2015.

These financial statements should be read in conjunction with the financial statements and the accompanying notes and other information included in Noble Energy's Quarterly Report on Form 10-Q to be filed with the Securities and Exchange Commission on August 3, 2015.

NOTE: Discretionary cash flow should not be considered an alternative to, or more meaningful than, net income (loss), net cash provided by operating activities, or any other measure as reported in accordance with GAAP. The table above reconciles discretionary cash flow to net cash provided by operating activities. While discretionary cash flow is not a GAAP measure of financial performance, our management believes it is a useful tool for evaluating our overall financial performance. Among our management, research analysts, portfolio managers and investors, discretionary cash flow is broadly used as an indicator of a company's ability to fund exploration and production activities and meet financial obligations. Discretionary cash flow is also commonly used as a basis to value and compare companies in the oil and gas industry. However, Noble Energy's method of computing this measure may not be the same method used to compute similar measures reported by other entities.

[1] See Schedule 1: Reconciliation of Net Income (Loss) to Adjusted Income.

[2] Increase in capital lease obligations represents estimated construction in progress to date on US operating assets and corporate buildings.